Intelligent mud-gas separation and handling system

ABSTRACT

A multi-phase fluid solution measurement and gas separation system is described. The system includes a substantially vertical fluid supply pipe that introduces the multi-phase fluid solution in a steady flow having a substantially calm and steady fluid surface to a mud-gas separation unit. The mud-gas separation unit includes measurement tools such as force sensors and level sensors to allow for a rheological model of the fluid to be calculated. The system also includes components for flaring or processing gas which separates from the multi-phase solution.

PRIORITY CLAIM

This application claims priority as a divisional application of U.S.patent application Ser. No. 15/677,561, filed Aug. 15, 2017, with thesame title. The application is incorporated by reference in itsentirety.

BACKGROUND

Many operations in the oilfield involve extracting a multi-phase flowfrom a formation which can contain uncertain quantities of mud,hydrocarbons, gas, debris, and other fluids. There are tools for knowingthe precise quantity of each component in the multi-phase flow, such asa VX flow meter, but many of these methods are prohibitively expensive.Knowing the precise quantity of each component in the multi-phase flowwithout using expensive equipment can be a challenging proposition.Another challenge is to separate gas phase components of the fluid fromthe liquid phase components. There is a need in the art for aninexpensive, reliable method to ascertain the characteristics of amulti-phase fluid flow and separating gas from liquid phase components.

SUMMARY

Various features of the present disclosure are described herein withreference to the accompanying figures. Embodiments of the presentdisclosure are directed to a multi-phase fluid flow measurement systemincluding a fluid supply pipe oriented in an at least partially verticalorientation. The fluid supply pipe can carry a multi-phase fluid upwardthrough the fluid supply pipe. The multi-phase fluid has anupwardly-facing fluid surface. The system can also include a transferpipe extending laterally from the fluid supply pipe. The multi-phasefluid is pressurized sufficiently to flow through the transfer pipewhile the upwardly-facing fluid surface is steady and remains steady asit enters the transfer pipe. The system also has a Weir plate positionedto at least partially impede the flow of the multi-phase fluid throughthe transfer pipe. The system can have a level sensor in the mud-gasseparator configured to measure a level of fluid accumulated in themud-gas separator unit, and a controller configured to release at leastone of fluid or gas from the mud-gas separator in response to the levelsensor determining that the fluid level has reached a predeterminedlevel.

Other embodiments of the present disclosure are directed to a method ofmeasuring characteristics of a fluid in a multi-phase solution. Themethod includes conducting a multi-phase solution in a verticaldirection such that the multi-phase solution forms an upwardly-facing,steady fluid surface, and flowing the multi-phase solution laterallythrough a transfer pipe. The transfer pipe is at least partially blockedby a Weir plate. The method also includes flowing the multi-phasesolution over one or more baffles positioned at a downwardly slopingangle, and measuring a depth of the multi-phase solution as it flowsover the baffles in at least one location. The method also includesallowing gas to escape the multi-phase solution and collecting theescaped gas.

In still further embodiments the present disclosure is directed to amud-gas separation unit including an inlet configured to receive asteady flow of a multi-phase solution and a baffle having a forcesensor. The baffle is positioned so that the steady flow impinges uponthe baffle on an area affected by the force sensor. The mud-gasseparation unit also includes a gas collection region above the inletconfigured to allow gas to escape the multi-phase solution and collectin the gas collection region, and an articulating member operativelycoupled to the baffle and configured to change an angle of the baffle.

BRIEF DESCRIPTION OF THE FIGURES

FIG. 1 is a schematic illustration of an environment 90 for a gasseparation/flow measurement component according to embodiments of thepresent disclosure.

FIG. 2 is an illustration of the separation component according toembodiments of the present disclosure.

FIG. 3 shows some dimensions and parameters for use with horizontal andtriangular Weirs.

FIG. 4 is a diagram of a measurement to be carried out according toembodiments of the present disclosure including a sloped baffle and alevel sensor.

FIG. 5 is a schematic illustration of a mud-gas separator as part of aseparation component according to embodiments of the present disclosure.

FIG. 6 is a schematic illustration of a separation component accordingto embodiments of the present disclosure.

FIG. 7 shows yet another separation component according to still furtherembodiments of the present disclosure.

DETAILED DESCRIPTION

Below is a detailed description of systems and methods for analyzing andseparating fluids of different phases from a multi-phase fluid flowaccording to embodiments of the present disclosure. Reference is made tocertain example structures and techniques and it is to be understood bya person of ordinary skill in the art that these examples andillustrations are not given in a limiting manner; rather, a person ofordinary skill in the art will recognize that the scope of the presentdisclosure is greater than specific embodiments and illustrations.

FIG. 1 is a schematic illustration of an environment 90 for a gasseparation/flow measurement component 100 according to embodiments ofthe present disclosure. The gas separation/flow measurement component100 will be referred to herein as a separation component 100 withoutloss of generality. A multi-phase flow is produced during manyoperations, including drilling, completions, etc. The environment shownin FIG. 1 includes a pipe 102 carrying a multi-phase flow from aformation. The environment 90 can also include a blowout preventer (BOP)104 comprising a large valve at the top of a well that may be closed ifthe drilling crew loses control of formation fluids. By closing thisvalve a drilling crew can regain control of the reservoir, andprocedures can then be initiated to increase the mud density until it ispossible to open the BOP 104 and retain pressure control of theformation. The environment 90 can also include a rotating control device(RCD) 106, which can be a pressure-control device used during drillingfor the purpose of making a seal around a drillstring (not shown) whilethe drillstring rotates. The RCD is intended to contain hydrocarbons orother wellbore fluids and prevent their release to the atmosphere. Thesecomponents deliver a flow of multi-phase fluid to a managed pressuredrilling (MPD) choke manifold 108. MPD 108 is a technique using anadaptive drilling method used to precisely control the annular pressurethroughout a wellbore. After determining the downhole pressureenvironment, drillers manage wellbore pressure constrained by the limitsof formation properties. The annular pressure is kept slightly above thepore pressure to prevent the influx of formation fluids into thewellbore, but it is maintained well below the fracture initiationpressure. Rapid corrective actions can often be implemented in order todeal with observed pressure variations. The MPD process may utilize avariety of techniques including control of back pressure, adjusting muddensity, modifying fluid rheology, adjusting the annular fluid level,controlling circulating friction and incorporating hole geometry in thewell construction.

The use of MPD and the MPD manifold 108 to control the risks and costsof drilling wells that have narrow downhole pressure limits by activelymanaging the wellbore pressure profile has become a common practice. Thedynamic control of annular pressures enables drilling wells that mightnot otherwise be practical. The MPD manifold 108 delivers themulti-phase flow to the separation component 100, where it is analyzedand separated into a gas 110 and a fluid 112 outflow.

FIG. 2 is an illustration of the separation component 100 according toembodiments of the present disclosure. The separation component 100includes a fluid supply pipe 120, a transfer pipe 122 and a mud-gasseparator (MGS) 124. The transfer pipe 122 includes a barrier such as aWier plate 126. The transfer pipe 122 can be shaped to allow fluid flowthrough it to be relatively thin in the vertical dimension whichencourages gas to separate from the liquid of the flow. There is a gastransfer conduit 128 above the transfer pipe 122 which permits gas toflow freely between the supply pipe 120 and the MGS 124. The fluidsupply pipe 120 includes a supply box 130 at an upper portion of thesupply pipe 120. The supply box 130 includes a level sensor 132configured to measure a distance from the top of the supply box 130 tothe surface 134 of the multi-phase flow introduced through the fluidsupply pipe 120. The MGS 124 has one or more baffles 136 a, 136 b, and136 c. There is a fluid outlet 138 at a base of the MGS 124, and a gasoutlet 140 at a top of the MGS 124.

The fluid supply pipe 120 provides a multi-phase flow received from theMPD manifold 108 shown in FIG. 1. The multi-phase flow can include mud,oil, water, gas, and cuttings or other detritus usually present in adrilling operation or another oilfield operation. The fluid supply pipe120 is oriented with a substantial vertical component. In FIG. 2, thesupply pipe 120 is vertical, although in other embodiments there is ahorizontal component to the orientation of the fluid supply pipe 120.Pressure in the multi-phase flow causes the flow to have an uppersurface 134 which is raised above the level of the transfer pipe 122such that fluid flows through the transfer pipe 122, through the Weirplate 126, and into the MGS 124. Within the multi-phase flow are gasbubbles 142 which are encouraged to exit the multi-phase flow from theupper surface 134 and congregate above the surface 134 as shown by thegas cloud 144. This gas is permitted to pass between the supply box 130and the MGS 124 through the gas transfer conduit 128 and ultimately outof the MGS 124 through the outlet 140. The supply box 130 can beconstructed having certain dimensions to encourage effective gasseparation and to promote a steady flow through the Weir plate 126. Thetop surface of the fluid is maintained level due to the dimensions ofthe supply box 130. The multi-phase fluid flow allows gas bubbles toexit the flow, and by exiting they can cause disturbances in thesurface. The enlarged supply box 130 mitigates these disturbances andallows the flow to remain steady, and stable. The vertical variances inthe level of the flow are minimized which allows for more reliablemeasurements as the fluid continues onward through the MGS 124. In someembodiments, the area of the surface 134 is such that the flow remainssteady.

The vertical component of the fluid supply pipe 120 ensuresestablishment of a velocity profile for the fluid. The size of thesupply box 130 ensures that the flow is calm and steady as it reachesthe exposed fluid surface 134 and begins to flow into the MGS 124. TheWeir plate 126 can be square or triangular as shown.

FIG. 3 shows some dimensions and parameters for use with horizontal andtriangular Weirs. For a horizontal-crested rectangular weir, where A=hL,the calculation of flow rate, Q, can be found using the followingequation:

Q=C _(d) Lh√{square root over (h _(t))}≈C _(d) Lh ^(3/2)

In the case of a triangular, or V-notch Weir, where

${A = {h^{2}{\tan \left( \frac{\theta}{2} \right)}}},$

the calculation or flow rate, Q, can be found using the followingequation:

$Q = {{C_{d}{{Lh}\left( \frac{\theta}{2} \right)}h^{2}\sqrt{h_{t}}} \approx {C_{d}{\tan \left( \frac{\theta}{2} \right)}h^{5/2}}}$

When considering such relation for weir plates, it can be observed thatthe fluid density does not affect the flowrate, as the density affect ina linear way the potential energy in the supply region to the weir plateand also the kinetic energy of the flow falling through the weir plate.If the fluid contains gas bubbles which are entrained by the fluidthrough the weir plate opening as the same velocity, the system would sodetermine the total flowrate. Such two-phase flow measurement appliesfor gas bubble moving horizontally as the same velocity than the liquid.This is particularly applied for small bubbles and with viscous fluid.The gas which escapes from the multi-phase flow in the supply box 130 tothe MGS 124 via the pipe 128 may be measured by a gas flowmeter 165.Such flowmeter may be an ultra-sonic time of flight measurement system.

Referring back to FIG. 2, the multi-phase fluid cascades downward underforce of gravity over the baffles 136 a-136 c and can collect at thebottom of the MGS 124 or it can be selectively allowed to leave the MGS124 via the fluid outlet 138. As the fluid cascades over the baffles,gas continues to separate from the fluid and continues to collect at thetop and to exit the gas outlet 140. With reference to the first baffle136 a, there is a force sensor 150 at the higher portion of the baffle136 a that is configured to measure and record the force imparted to thebaffle 136 a from the falling fluid flow. There can be many forcesensors 150 positioned along the baffle 136 a or on another suitableportion of the MGS 124. There can be a vertical drop 152 from the baseof the transfer pipe 122 to the baffle 136 a which enables the forcesensor 150 to measure the impact of the falling fluid, taking intoconsideration the vertical drop 152. In some embodiments the verticaldrop 152 may not be purely vertical and may have some horizontalcomponent. In some embodiments the vertical drop 152 is negligible. Thebaffle 136 a can have a generally consistent slope along its length. Insome embodiments the baffle 136 a can include an articulated portion 154a which rotates about a fulcrum 156 a. The articulated portion 154 isshown in two positions to illustrate the movement. The system may beequipped with one or more level sensors 162 a, 162 b, and 162 c tomeasure the fluid level above the plate 154. There can be a secondfulcrum 156 b and articulated portion 154 b on a second baffle 136 b or136 c. The difference in slope allows for yet another calculation to bemade on the fluid flow according to the two-rheological model with twoparameters: the depth of the fluid as it flows along the baffle 136 aand the angle of the articulated portion 154. This measurement andcalculation can be made according to the Bingham plastic law or thepower law. The same measurement can be made at any point along any ofthe baffles 136 a, 136 b, or 136 c.

FIG. 4 is a diagram of a measurement to be carried out according toembodiments of the present disclosure including a sloped baffle 160 anda level sensor 162. The level sensor 162 c can be positioned at variouspoints along the flow path of the multi-phase fluid flow in theseparation component 100. It can be used to measure the depth of theflowing fluid using the following equation:

$V = {\frac{{De}^{2}}{3\mu}\rho \; g\frac{dz}{dx}}$

Where:

V=average velocityDe=max depth of the flowing channelρ=fluid densityμ=fluid viscosityz=vertical coordinatex=axial coordinate along the flow channel.

The fluid level may be obtained by measurement of the layer of fluidabove the baffle plate (such as 162 c of FIG. 4. Such sensor could bebased on inductance or capacitance measurements or even pulsedultra-sonic detector. In other applications, the fluid level above thebaffle plate 154 may be obtained by distance sensor 162 a or 162 c oreven 132 which measure the gap between the sensor face and the surfaceof the fluid, allowing to determine the correct level of fluid.

Using these calculations, the flow rate from within the transfer pipe122 through the Weir plate 126 can provide an estimation of flow rate.The force sensor 150 (also referred to as a target sensor) can providean estimate of fluid density ρ. The level measurement 162 a above thebaffle 136 a can provide an estimation of apparent viscosity, where

$\frac{dz}{dx}$

is the slope of the baffle plate 160 which is defined by theconstruction of the MGS 124.

The additional feature of the articulating plate 154 provides yetanother measurement, which enables use of the “two rheological model”with two parameters. For such application, the level sensor 162 b can beinstalled above this articulating plate 154. This can be achieved usingthe Bingham plastic law or the power law. In some embodiments there is asecond baffle having force sensors and an articulation. FIG. 2 showsbaffle 136 c as having these features. In some embodiments, the firstand last of the baffles can have these additional features. In otherembodiments all the baffles can have one or more of the force sensor andthe articulating portion. Identical (or similar) instrumentation on twoor more of the baffles may be installed such as the first and lastbaffles (IE, such as the baffle 136 a and baffle 136 c), it is possibleto determine the gas extraction performed within the MGS 124: thedensity would increase for the last plate, as gas would escape from thefluid. Also, the rheology may be affected: the fluid may appears moreviscous. In yet further embodiments the baffles can be formed in aspiral, continuous downward slope.

The MGS 124 shown in FIG. 2 can also be used to determine how muchmaterial is held within the MGS 124. Of course, the weight of the emptyMGS 124 is known ahead of time, and with the estimation of mass flowrate through the MGS 124, the weight of the fluid passing through theMGS 124 in a steady-state operation can be estimated. The differencebetween these two numbers and the operating weight of the MGS 124 atsteady-state flow operation will yield the weight of any detritus thathas collected within the MGS 124. Another method for determining theamount of accumulated material is to use a level sensor 155 operated bya controller 157. The level sensor may be a vibrating 155 which can bemade to vibrate to move the material and thus achieve a measurement ofhow much material there is. In other embodiments, the level sensor 155can be an electrode operated by the controller 157 and configured toelectrically (through capacitance or resistance) determine the quantityof material in the MGS 124.

FIG. 5 is a schematic illustration of a MGS 124 as part of a separationcomponent 200 according to embodiments of the present disclosure. Theseparation component 200 can receive a multi-phase fluid from a MPDManifold 202, similar to that described elsewhere herein. Themulti-phase fluid can be fed into the MGS 124 through a fluid supplypipe that is not shown in FIG. 5. The MGS 124 has baffles 136 which helpto encourage gas to migrate out of the fluid and naturally upward to thetop of the MGS 124. The gas can be delivered to a flare unit 204 to beburned away or otherwise disposed of. In other embodiments, the gas canbe delivered to a glycol tower 206 for drying and other treatmentwherein the gas eventually reaches production. The MGS 124 can also havea level sensor 155 capable of measuring a level of fluid within the MGS124. The MGS 124 can have a valve 210 at the bottom. The separationcomponent 200 includes a controller 212 and an actuator 214 operativelycoupled to the valve 210 and to the level sensor 208. When the level offluid 216 reaches a predetermined height, the controller 212 caninstruct the actuator 214 to open the valve 210 to release some of thefluid from the MGS 124 and into a shaker 218. The valve 210 can have agrate or another equivalent mechanical means to prevent debris fromclogging the valve 210. The controller 212 and level sensor 208 can helpto avoid a situation that may be caused when too much gas builds upwithin the MGS 124 in which excessive pressure drop in the flare linecauses gas to exit the MGS through the valve 210 and into the shaker218. In other conventional embodiments in which there is no valve 210,the excessive pressure drop in the flare line (between 124 and 204) cancause the gas to push the fluid level downwards in the MGS 124 with riskthat the gas reach the shaker 218 or other downstream components. Withthe embodiment of FIG. 5, the controller 212 and level sensor 208prevent such occurrence by opening and closing the valve 210 to keep thefluid level in the proper range of level.

FIG. 6 is a schematic illustration of a separation component 201according to embodiments of the present disclosure. Some features ofthis separation component 201 are generally analogous to components fromFIG. 5. The separation component 201 includes a MGS 124 which separatesand measures fluid and gas as discussed in detail above. This separationcomponent 201 further includes a pressure sensor 220 within the MGS 124.The sensor 220 can be any suitable type of pressure sensor and can bepositioned within or without the MGS 124 and is configured to measure apressure in the gas inside the MGS 124. The pressure sensor 220 iscoupled to a controller 212. The separation component 201 also includesa compressor 222 in fluid communication with the gas exiting the MGS124. The compressor 222 can deliver the gas to the flare 204 or to aglycol tower 206 or to another production line. If the pressure withinthe MGS 124 reaches a certain threshold some gas can be moved throughthe compressor 222 and delivered to its next destination. In someembodiments the compressor 222 can selectively deliver the gas to aflare 204 or a glycol tower 206. The pressure within the MGS 124 is alsorelated to the level of fluid within the MGS 124. The separationcomponent 201 includes a level sensor 208 for measuring the level offluid 216 within the MGS 124. In some embodiments the pressure sensor220 can eliminate the need for the level sensor 208. In otherembodiments the pressure sensor 220 and level sensor 208 are both incommunication with the controller 212 which can also communicate withthe valve 210 to permit selective opening and closing of the valve torelease fluid from the MGS 124.

Furthermore, the line to flare system may be terminated by a nozzle 221.Through such nozzle, the pressure may accelerate the gas to a sonic oreven super-sonic velocity. Such high velocity provides an excellentmethod to entrain air so that the fuel/oxygen ratio is better and allowsa cleaner combustion of the gas at the flare. The compressor may becontrolled by the controller 212 in relation with the measurement of apressure gauge 223 coupled between the compressor 222 and the flare 204and the setting on the choke (in the case of variable gas nozzle 221).With optimum setting of the nozzle 221 versus the pressure gauge 223,the fuel/oxygen can be optimized. Also, the usage of nozzle 221operating above the sonic velocity acts as a flame arrester. Thisinsures that the flame cannot move inside the gas supply line back tothe inside of the MGS 124. Such situation may exist at start of the MGS124, as the inside of the MGS 124 is initially filled with air. So, theinitial gas flow through the compressor 222 towards the nozzle 221 is amixture of flammable gas and air (oxygen) with the potential risk of theflame moving back from the flare towards the inside of the MGS 124(which should be monitored for explosion).

Furthermore, the compressor 222 may also be designed and operated aspartial vacuum pump. It such application, the pressure inside the MGS124 (measured by the pressure gauge 220) may be low, helping theextraction of gas out of the supplied fluid. If the gas is not insolution (but in bubble), the bubble increases in size and float fasterto surface to escape the fluid. In the gas is in solution, the lowpressure may provoke some de-absorption. For such operation at lowpressure in the MGS 124, the valve 210 can be coordinated with the levelmeasurement 208 by the controller 212.

Also the gas present inside the MGS 124 and line towards the flare stackmay be monitored for presence of toxic gas (such as H2S). In such case,a pilot flame may be activated (turned ON) at the flare to insure safehandling of such gas (by combustion). The MGS gas line to the flare 204may also include a gas analyzer 225 to determine the ratio of C1, C2,C3, and C4. Such analysis may be obtain by optical absorption ofspecific wavelength to determine the presence (and concentration) ofeach type of molecules. This analysis may be useful to estimate thecontent of gas emitted by some down-hole formations. This information isalso valuable to determine the optimum the air ration to entrain foroptimum burning at the flare.

FIG. 7 shows yet another separation component 203 according to stillfurther embodiments of the present disclosure. The separation component203 includes several features generally analogous to features from FIGS.5 and 6, and further includes a temperatures sensor 230 positionedwithin the MGS 124, a controller 212 c, and a heater 232 operativelycoupled to the controller 212 c and capable of heating the incomingmulti-phase fluid flow. The temperature sensor 230 prevents the heater232 from overheating the gas within the MGS 124. Certain predeterminedtemperature limits can be set to prevent overheating. Heating theincoming multi-phase fluid flow encourages the gas to migrate out of theflow. Referring to FIG. 2, the heater 232 can be positioned on the fluidsupply pipe 120 before reaching the supply box 130.

The separation component 203 includes several features generallyanalogous to features from FIGS. 5 and 6. Some embodiments can includeone or more of these components in any combination as will be understoodby a person of ordinary skill in the art. For example, a separationcomponent according to the present disclosure may include thetemperature sensor and heater and not the compressor 222. A singlecontroller can be used to control each of the level sensor and valve,pressure sensor and compressor, or the temperature sensor and heater. Inother embodiments, each of these systems can have a dedicatedcontroller. The separation component 203 can also include a PVT(pressure, volume, temperature) cell 224 positioned and configured tomeasure characteristics of the outgoing fluid flow from the MGS 124 tothe shaker 218. This data is used by the controller 212 b to determinewhether or not to operate the compressor 222 to allow or prevent gasfrom escaping from the MGS 124, or to selectively pump gas from the MGS124 according to the needs at a given time.

The systems and methods of the present disclosure enable a multi-phasefluid flow to be separated, gas from liquid, and measured for parametersaccording to Bingham's law, the power law, or another suitablecalculation, without the need for an expensive VX flowmeter or anothersimilarly expensive component.

1. A multi-phase fluid flow measurement system, comprising: a fluidsupply pipe oriented in an at least partially vertical orientation, thefluid supply pipe being configured to carry a multi-phase fluid upwardthrough the fluid supply pipe, wherein the multi-phase fluid has anupwardly-facing fluid surface; a transfer pipe extending laterally fromthe fluid supply pipe, wherein the multi-phase fluid is pressurizedsufficiently to flow through the transfer pipe while the upwardly-facingfluid surface is steady and remains steady as it enters the transferpipe; a barrier positioned to at least partially impede the flow of themulti-phase fluid through the transfer pipe; and a level sensorconfigured to measure a depth of the multi-phase fluid as it flows fromthe transfer pipe.
 2. The multi-phase fluid flow measurement system ofclaim 1 wherein the barrier is a Weir plate.
 3. The multi-phase fluidflow measurement system of claim 1, further comprising a mud-gasseparator (MGS) unit coupled to the transfer pipe and configured toreceive the multi-phase fluid.
 4. The multi-phase fluid flow measurementsystem of claim 3, further comprising a gas transfer conduit between thefluid supply pipe and the mud-gas separator unit.
 5. The multi-phasefluid flow measurement system of claim 1, further comprising a pluralityof baffles in the mud-gas separator, wherein at least one of the baffleshas a force sensor configured to measure kinetic energy within themulti-phase fluid.
 6. The multi-phase fluid flow measurement system ofclaim 5 wherein the level sensor is configured to measure the height ofthe flowing fluid above one or more of the baffles.
 7. The multi-phaseflow measurement system of claim 6 wherein the multi-phase fluid flowmeasurement system is configured to determine the apparent viscosity ofthe multi-phase fluid.
 8. The multi-phase fluid flow measurement systemof claim 5, wherein at least one of the baffles comprises anarticulating member configured to articulate to change an angle of thebaffle.
 9. The multi-phase fluid flow measurement system of claim 8, andassociated with the claim 3c to determine the apparent viscosity of thefluid at different flow conditions.
 10. The multi-phase fluid flowsystem of claim 9, wherein the multi-phase fluid flow measurement systemis configured to determine the rheological model of the multi-phasefluid.
 11. The multi-phase fluid flow measurement system of claim 5,wherein the level sensor comprises at least two level sensors, each on adifferent baffle, wherein the level sensors are configured to measure achange of at least one of density and rheology due to extraction of gas.12. The multi-phase fluid flow measurement system of claim 11, whereinthe difference of fluid properties may be measured on the first and lastbaffle plate, the multi-phase fluid flow measurement system isconfigured to determine the flow rate of gas extracted from themulti-phase fluid.
 13. The multi-phase fluid flow measurement system ofclaim 1 wherein the multi-phase solution includes at least one of mudand hydrocarbons.
 14. The multi-phase fluid flow measurement system ofclaim 3, further comprising a controller configured to release at leastone of fluid or gas from the mud-gas separator in response to the levelsensor determining that the fluid level has reached a predeterminedlevel.
 15. The multi-phase fluid flow measurement system of claim 3,further comprising a gas line configured to carry gas out of the MGSunit released from the multi-phase fluid.
 16. The multi-phase fluid flowsystem of claim 15, further comprising a sensor configured to enable adetermination of a type and amount of gas flowing through the gas line.17. The multi-phase fluid flow measurement system of claim 15, furthercomprising a compressor in the gas line.
 18. The multi-phase fluid flowsystem of claim 17, wherein the compressor is configured to feed a flarestack trough a variable choke orifice, the multi-phase fluid flow systemfurther comprising a pressure gauge in the gas line, and means forcontrolling a choke orifice at least in part in response to a pressuremeasured by the pressure gauge.
 19. The multi-phase fluid flow system ofclaim 18, wherein the compressor, the variable choke orifice, thepressure gauge, and the means for controlling the choke orifice areconfigured to entrain adequate air flow versus the ejected gas flow atthe nozzle.
 20. A mud-gas separation unit, comprising: an inletconfigured to receive a steady flow of a multi-phase solution; a bafflehaving a force sensor, wherein the baffle is positioned so that thesteady flow impinges upon the baffle on an area affected by the forcesensor; a gas collection region above the inlet configured to allow gasto escape the multi-phase solution and collect in the gas collectionregion; and an articulating member operatively coupled to the baffle andconfigured to change an angle of the baffle.
 21. The mud-gas separationunit of claim 20, further comprising a gas outlet and a fluid outlet,the fluid outlet being positioned at a lower portion of the mud-gasseparation unit.
 22. The mud-gas separation unit of claim 20, furthercomprising a force sensor on one or more of the baffles to determine afluid density of the fluid.
 23. The mud-gas separation unit of claim 22,wherein the force sensors are configured to measure the density of themulti-phase flow at 2 different baffles of the gas separator anddetermining the difference of fluid density from a first baffle and asecond baffle, wherein the quantity of gas is associated with a flowrate from the inlet.
 24. The mud-gas separation unit of claim 20,further comprising a heater configured to apply heat to the multi-phasefluid as it enters the mud-gas separation unit.
 25. The mud-gasseparation unit of claim 24, further comprising a temperature sensorconfigured to monitor a temperature within the mud-gas separation unitto prevent overheating.
 26. The mud-gas separation unit of claim 20,further comprising: a compressor; an associated controller associatedwith the compressor, the controller being configured to influence thecompressor; and a glycol tower configured to receive fluid from themug-gas separation unit to remove the water from the gas.